Turbulent flow tool

ABSTRACT

An apparatus ( 10 ) for mounting on a tubular ( 12 ) for location in a bore comprises a seal comprising a swelling sealing material adapted to permit passage of fluid cement between the tubular and the surrounding bore wall which is void of set cement. Alternatively, the sealing material may expand into a space between the tubular and surrounding set cement.

CROSS REFERENCE TO RELATED APPLICATIONS

This is a continuation of International Application No. PCT/GB2007/003140 filed on Aug. 17, 2007. Priority is claimed from British Patent Application No. 0616351.3 filed in Aug. 17, 2006.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not Applicable

BACKGROUND OF THE INVENTION

1. Field of the Invention

This invention relates to a downhole apparatus. Specific embodiments of the invention relate to a stop collar to provide sealing between a downhole tubular and a surrounding cement annulus.

2. Related Art

When a certain section of an oil and gas well has been drilled, there comes the time to case it with a pipe—called casing or liner—which is cemented into place. This process is also called primary cementing.

Primary cementing is the process of placing cement in the annulus between the casing and the formations exposed to the wellbore. Enough cement must be pumped to fill the annular column from the bottom up to at least that region across productive zones.

Several authors hold that primary cementing is the most important operation performed on a well. The cement performs vital functions in supporting the casing and wellhead equipment. The casing itself cannot perform the functions it is designed for unless effectively cemented in place. In addition, the cement forms a barrier to the passage of fluids from permeable formations. A poor cementation process can significantly impact the productivity of a well and if remedial costs (due to secondary cementing) are added, it adversely affects the return on investment.

The following are some of the purposes of well cementing that are relevant to embodiments of the present invention:

-   -   Zonal isolation: Cement provides a pressure-tight seal that         stops annular space communication between permeable formations.     -   Corrosion protection: Cement isolates the pipe from corrosive         gases and liquids released from the formations.     -   Well abandonment: the cement avoids fluids contained in         open-hole sections (i.e. uncased) from reaching surface (e.g.         loss of containment).

A good cement job isolates the wellbore from the casing. This isolation ensures that no hydrocarbons can escape to surface and eliminates the possibility of corrosion of the downhole tubular by formation fluids which are a high probability event if there was communication between the wellbore fluids and the tubular.

Notwithstanding technology advancements, the drive to meet global production demands has meant that there is a requirement to drill ever more complex well-bores often through difficult geological formations (i.e higher risk of well bore instability). This frequently results in higher incidences of remedial casing cementing operations.

It is known that wellbore cementation has a number of potential failure modes which include:

a) incorrect cement formula causing the cement to become brittle during the life of a well or that the cement does not harden properly and the flow of hydrocarbons takes place;

b) further well construction or remedial work-over operations cause such impact so as to weaken or fracture the cement bond (e.g. hydraulic jarring);

c) the casing or liner may be too smooth for the cement to adhere to and thus create a less than optimal bond;

d) physical damage or bond fatigue by pressure and temperature cycling;

e) chemical damage by the addition of other fluids into the wellbore including acid washes, etc, introduced through remediation cement ‘squeezes’, perforation and reservoir permeability improvement activities.

Even when the casing/liner and cement are successfully placed, various mechanical, operational or chemical factors may result in an incomplete cementation and subsequently lead to the development of fluid channelling by various means, including the formation of channels and/or micro annuli within the cement, as illustrated in attached FIGS. 1 a, 1 b, 1 c and 1 d.

In particular, the Figures illustrate cementing failures in the form of: a lack of cement in a section (FIG. 1 a); and the presence of conductive canals, such as a microannulus (FIG. 1 b) or channelling (FIG. 1 c), and fluid migration problems (FIG. 1 d).

Ultimately, this can lead to hydrocarbons escaping towards the surface (often referred to as “loss of containment”) and loss of reservoir fluids due to cross flow along the cement sheath and between zones. There could also be influx of fluids from other formations into the active layer, resulting in mixing (FIG. 1 d). For an injector well, injected fluids could escape into neighbouring zones, compromising the efficiency of the stimulation.

Inventors interested in optimising the efficiency of constructing subterranean wells have focused on improving cementation operations by improving casing centralisers, casing scratchers, reaming shoes and various float equipment among the like. One of the great advancements has been the ability to rotate the casing or liner into the wellbore which has introduced the possibility of reaming with the casing into the wellbore in the event of encountering a downhole obstacle.

Over the last 60 years or so it has been common to use casing centralisers and the like to ensure that downhole tubulars are placed equidistant within the wellbore wall for cementation purposes. This allows cement to flow uniformly around the centraliser and casing.

Since the introduction of centralisers, there have been many innovations in the area of material selection, design and functionality, and stop collars have been introduced to be used in combination with centralisers to limit the axial movement of the centralisers.

There have been numerous advances in the use of blade patterns in a centraliser face to alter the velocity and kinetic energy of fluid, cuttings and cement flow. With respect to stop collar design there have been fewer advances, although there have been innovations relating to the method of attaching the stop collar to the tubular and how the stop collar engages with the mating centraliser to offer additional mechanical capabilities as an assembly: these advances are described by Herrera in U.S. Pat. No. 2003/0106719 A1, the disclosure of which is incorporated herein by reference.

SUMMARY OF THE INVENTION

According to the present invention there is provided downhole apparatus for mounting on a centraliser for location in a bore, the apparatus comprising a seal comprising a swelling sealing material adapted to permit passage of fluid cement between the tubular and a surrounding bore wall and for subsequent volumetric expansion into a space between the tubular and the surrounding bore wall which is void of set cement.

According to another aspect of the present invention there is provided a method of sealing a tubular in a bore, the method comprising: providing swelling sealing material on a tubular pipe; running the tubular into a bore; and circulating fluid cement into the annulus between the tubular and the bore wall, whereby the swelling sealing material will subsequently swell into a space between the tubular and the surrounding bore wall which is void of cement.

The space between the tubular and the bore wall may be partially filled with cement such that the swelling sealing material expands to fill the remainder of the space between the cement and the tubular. Alternatively, where no cement is present, the swelling sealing material expands to fill the space between the tubular and the bore.

According to another aspect of the present invention there is provided downhole apparatus for mounting on a tubular for location in a bore, the apparatus comprising a seal comprising a swelling sealing material adapted to permit passage of fluid cement between the tubular and a surrounding bore wall and for subsequent volumetric expansion into a space between the tubular and the surrounding set cement.

According to another aspect of the present invention there is provided a method of sealing a tubular in a bore, the method comprising: providing swelling sealing material on a tubular; running the tubular into a bore; and circulating fluid cement into the annulus between the tubular and the bore wall, whereby the swelling sealing material will subsequently swell into a space between the tubular and the surrounding cement.

The apparatus may be configured to create turbulence in fluid passing between the apparatus and the surrounding bore wall. The fluid may be well fluid, fluid cement, drilling fluid or the like. This embodiment of the present invention advantageously provides an apparatus which augments the overall casing cementation process by enhancing downhole turbulence to ensure effective downhole isolation. The downhole turbulence may be affected by at least one of apparatus design, profile and materials engineering. The latter may be accomplished by incorporating swellable turbulating materials in the apparatus, which will grow in size after interacting with the wellbore fluids and seal the annular spaces between the cement or the formation and the apparatus and optionally between the apparatus and the tubular, resulting in an in-situ cement squeeze. Other embodiments of the invention may not be configured to provide such turbulence.

The apparatus may include attaching means for securing the apparatus to the tubular. The attaching means may take any appropriate form, including set screws, grub screws, bolts, shear pins, adhesives, welding, threaded connections, or by another suitable arrangement as would be recognised by someone skilled in the art.

The apparatus may include a turbulating element adapted to enhance turbulence of wellbore fluids and cement or the like. The turbulating element may include swelling sealing material adapted to react and interact with wellbore fluids and to swell. The swelling sealing material may be adapted to swell slowly, or swelling may be delayed to allow cement to be circulated and set around the tubular. The turbulating element may comprise one or more of a range of different materials and material forms, which include but are not necessarily limited to rings, o-rings, foam, elastomers, thermoplastics, thermosets and the like. The turbulating element can be manufactured from either natural or synthetic materials, in single, multiple or compound phases, have any particular cross-section area, shape or profile, hardness or strength, surface finish, have internal supporting components such as, but not limited to, springs or metal or plastic, or any other reinforcing material, such as, but not limited to, glass fibre, PTFE, carbon fibre or multi-ply construction cross-section. If manufactured from elastomers, possible materials could be natural rubber, styrene butadiene rubber, ethylene propylene monomer rubber, ethylene propylene diene monomer rubber, ethylene propylene copolymer, ethylene propylene diene terpolymer, ethylene vinylacetate rubber, hydrogenated acrylonitrile butadiene rubber, acrylonitrile butadiene rubber, butyl rubber, halogenated butyl rubber, brominated butyl rubber, chlorinated butyl rubber, isoprene rubber, chloroprene rubber, chlorinated polyethylene, polynorbornene, and starch polyacrylonitrile graft copolymers.

The swelling of the swelling sealing material may be initiated or triggered by a selected triggering material, typically a fluid, which may be a hydrocarbon, such as bitumen, oil or gas, water, cement or cement components or additives that can be encountered in a borehole. The triggering material may cause a change in the surface or boundary of the swelling sealing material.

Alternatively, or additionally, swelling of the swelling sealing material may be initiated by a selected triggering condition or stimulus such that as an electric current, pressure, temperature or the like. Swelling may be initiated by an in-situ temperature increase caused by curing cement.

The swelling material may be a swelling elastomer. The swelling elastomer may be selected from the materials listed in attached Table 1. Within this group of compounds, a sub-group of materials may be identified, based on operating ranges and known reliability in the oil and gas industry, and these compounds are listed in attached Table 2. Specific materials identified as appropriate for embodiments of the invention include: TFE-720-75, TFE-820 and TFEP-920, as supplied by Cri-Tech, Inc. of Hanover MA: VITON 60 Black, VAMAC 70 and SILICONE 65, as supplied by the Harboro Rubber Company Limited; and the ENDURA materials V91J and A90H supplied by Precision Engineering Limited.

The apparatus may include a carrier providing mounting for the swelling sealing material. In one embodiment the carrier carries a turbulating element. The carrier may comprise a machined component, or may comprise a component formed as a casting from one or more of a range of suitable casting processes, including card casting, die casting, wax casting or by some other means available to mass produce the said part as recognised by someone skilled in the art.

The apparatus may include one or more stop rings for mounting on the tubular. The stop rings may include attaching means for coupling the stop rings to the tubular. The stop rings may be utilised to secure a carrier and turbulating element, or to secure the turbulating element to the tubular when there is no carrier and the turbulating element is installed directly in the tubular.

The apparatus may include an interacting device for monitoring downhole conditions. The device may comprise a material or device adapted to determine, identify, record or measure one or more of external pressure, temperature or a change in the ambient conditions post cementing. The interacting device may be adapted to release a dye, paint or chemical in response to selected wellbore conditions, including the presence of wellbore fluids or the swelling of the swelling sealing material or a turbulating element The apparatus may define an outer diameter the same or less than the maximum diameter defined by the tubular or by a part of the tubular. For example the apparatus may define an outer diameter the same or less than a casing connector.

A preferred embodiment of the invention comprises an apparatus that is installed on the outer diameter of casing or liner, that is designed to enhance flow turbulence past the apparatus and which comprises, carries, contains or traps a turbulating element which when in contact with a triggering fluid or fluids reacts and interacts to grow in size, including but not necessarily limited to the swelling of material due to fluid entry, and occupy the empty space, if any, in the annulus between the apparatus and the tubular body to which the apparatus is mounted and in the annulus between the apparatus and the cement or, if cement is not present due to cementing problems, the formation. In this way, the apparatus is used to provide hydraulic isolation between the casing and the cement.

The turbulating element may be carried by, contained in or trapped by other elements of the apparatus and may be tailored to remain in its original form, for example unswelled, for a time long enough to allow the apparatus to be installed with the casing, liner or tubular and give additional time for well operations to be completed before the turbulating element grows.

The turbulating element may be designed to respond and grow in size to certain specific fluids at any given time after installation and in the absence of these said fluids to remain in its original state. As noted above, the apparatus may be designed to promote turbulence, and this may be achieved by a number of means, including but not limited to:

1) Designing the apparatus to have a change in cross sectional area, hence creating a pressure drop and subsequent turbulence.

2) Having a turbulating element with turbulent paths, blades or vanes.

3) Having a carrier with turbulent paths, blades or vanes in the area where the turbulating element is installed or in the areas where no turbulating element is installed or in stop rings surrounding the turbulating element.

4) Having corrugation due to placing turbulating elements next to each other along the carrier.

The apparatus may comprise a stop collar to act alone or in cooperation with other downhole equipment, such as but not limited to casing centralisers. When used in combination with a centraliser, the apparatus adds value to all existing casing centralisers, by not only providing a new apparatus and method which longitudinally locates a casing centraliser but which may optionally also react and interact with the wellbore fluid to further promote the turbulent flow of cement during the casing cementation process and also to effectively isolate the annulus between the apparatus and the cement or, if cement is not present due to cementing problems, the formation.

Embodiments of the invention seek to provide a secondary method in which to assure against the possibility of leaks of reservoir fluids between the casing or wellbore annulus after the cementation process. By ensuring against leaks, the apparatus represents a barrier to flow. The invention also relates to the provision of a plurality of seals along the length of the wellbore, which seal may be installed on several different casing sizes in order to establish several barriers to flow and seal between the casing and the cement in those areas where there is a microannulus or channel. This configuration utilising multiple and numerous incidences further assures against the possibility of fluid migration from the reservoirs towards the surface and the environment.

Another method in accordance with an aspect of the present invention involves the use of a plurality of seals in a casing section as a means of avoiding gas migration in the annular space upon secondary breakdown of the cement sheath.

Aspects of the invention relate to a method of using a casing or liner with a stop collar and centraliser, or the stop collar without a centraliser, for cementing operations, such that in the event of a less than perfect cement job the swelling sealing material of the stop collar has the ability to grow or swell thereby creating a barrier to seal the annulus between the apparatus and the cement or, if cement is not present due to cementing problems, the formation.

Embodiments of the present invention also provide the means and method in which to host within the apparatus a secondary device that can determine, identify, register, measure or record pressure, temperature or flow or at least one aspect of the wellbore or a change of any of these and which data can be accessed by a wireless, pipe or wireline conveyed tool. The secondary device may release, through time release or other directly or indirectly controlled method, a third party agent into the wellbore, for example a DNA or nucleonic or dye incorporated in the materials as to colour or tag the fluids in contact with the device so that when being observed at surface or in the wellbore by a suitable measuring device, the fluids can be depth tagged.

In another embodiment, the apparatus could be used only once in surface casing, giving the operator monitoring and controlling capabilities over gas influx in the annulus between the surface section and the cement.

The apparatus may comprise materials that provide galvanic protection to the casing, by offering a device more susceptible to corrosion.

In one embodiment of the present invention, a stop collar is provided and comprises a carrier and a secondary element installed in the carrier. The stop collar is placed on the outer face of the casing and has an outside diameter smaller than that of the casing collar. The stop collar may be secured to the tubular via set screws, grub screws, bolts, shear pins, adhesives, welding, threaded connection or by another suitable arrangement. The stop collar may be designed as to promote turbulence of bypassing fluid during installation of the tubular or during the cementing phase.

In one embodiment the turbulating element comprises injection moulded elastomer, said elastomer then being stretched over into specially designed recesses or receptacles within the main body of the carrier. Alternatively, the elastomer may be applied directly onto the carrier by an injection moulding process or similar, coupled to the carrier using cooperating threads or other connections to allow easier to achieve isolation.

In one embodiment a covering, such as a relatively impermeable shroud or membrane, is used to isolate the turbulating element from fluid in the borehole. The membrane may age with time, pressure or temperature and under selected conditions is breached to enable a specific fluid (for example hydrocarbons, water or gas) to enter and to make contact with the turbulating element and thereby activate the growing or swelling process.

In another embodiment, the turbulating element is coated with a substance, for example a paint, designed to degrade or embrittle over time and/or under certain conditions to act as an impermeable barrier over a predetermined period of time and which will then, due to design, age, thermally degrade or chemically react in the downhole environment to embrittle and crack or chemically dissolve and thereby expose the turbulating element and activate the growing or swelling process.

In one embodiment, a cured elastomer is bonded onto the stop collar. The elastomer may be shaped to induce flow turbulence. The cured elastomer may react and interact with the borehole fluid in order to grow in size and occupy gaps in the annular space.

In one embodiment, a cured elastomer is bonded onto a centraliser shaped to induce or flow turbulence as described in U.S. Patent Application Publication No. 2003/0106719 A1 by Herrera.

Another embodiment of this invention contemplates a downhole tubular device for mounting on a tubular, the device comprising a plurality of blades on an outer surface of the device which blades describe a smaller outer diameter than those of a centraliser adapted for mounting on the tubular.

The blades may be configured such that the action of fluid passing the device causes the device to rotate and thus enhance turbulence.

A stop collar in accordance with an embodiment of the invention may include a profiled or smooth ring of appropriate geometrical cross section to create a path for turbulence.

The stop collar may comprise a coating or outer layer applied to the turbulating element so as to change the surface profile of the element. The coating may promote turbulent flow.

In one embodiment the apparatus a rough, variable or changing surface finish, which affects the fluid flow of the cement but also improves the cement bonding to the device.

In one embodiment, the apparatus comprises two stop rings and a carrier in between. There is a gap between each stop ring and the carrier, so that the carrier is able to move up or down between the stop rings. The carrier may comprise a turbulating element with additional paths of turbulence through use of extended elastomeric elements which, when rotated, due to the passing of well fluid, cause additional turbulence through propeller or turbine type rotation.

In one embodiment the stop collar can be used to provide a secure datum point for casing centralisers. The stop collar may have an inner diameter greater than that of the outside diameter of the tubular and an outer diameter which is less than that of a co-operating centraliser, the purpose of the centraliser is to centralise the casing in a wellbore, such that the contact of the turbulating element with the wellbore during installation of the casing is minimised.

The stop collar may be adapted to reduce the friction of the bearing surfaces between the centraliser and the stop.

In another embodiment, an o-ring or multiple o-rings are installed directly onto the body of the casing or liner tubular in singular or plurality and with the option of several combinations of triggering phase are trapped by stop rings. Each o-ring may be designed to react and interact with certain types of fluid (water, oil, gas, cement) present in the borehole fluid in order to grow in size and occupy gaps in the annular space. Since the o-rings can be installed directly onto the body of the casing, a uniquely configurable assembly can be made up, at will, either in an on-site or off-site yard or on the rig floor. In one method, apparatuses having an o-ring or multiple o-rings as turbulating elements are installed in a clustered fashion along a tubular. Further, any one cluster of o-rings in one place may be made up of a number of o-rings with different properties (i.e. will react with the wellbore environment and/or fluids in that environment) such that any particular cluster will therefore react to a multitude of different wellbore conditions and/or fluids in that environment. Further any individual tubular may have a number of clusters along its length. Such an o-ring or o-rings may be trapped in place by a stop collar and a casing centraliser, such as the one described in U.S. Patent Application Publication No. 2003/0106719 A1 by Herrera.

The apparatus, which as noted above may simply comprise an o-ring, may be provided in relatively large numbers on a tubular string, for example one apparatus per joint, or in larger numbers. Each individual apparatus may be relatively compact, for example less than 1 metre in length, preferably less than 50 cm in length, or most preferably less than 30 cm. Each apparatus may be less than 15 cm in length. Such relatively small apparatus may be relatively inexpensive to supply. Providing multiple seal locations provides redundancy, and minimises the significance of an individual seal failure.

In another embodiment, an o-ring or multiple o-rings are placed in grooves on a carrier sleeve, which carrier sleeve in turn is secured to the tubular by set screws, grub screws, bolts, shear pins, adhesives welding, threaded connection, or by another suitable arrangement. The grooves in the carrier are designed to be perpendicular with respect to the main axis of the tubular. Each individual o-ring or groups of individual o-rings that form a subset of the total number of o-rings mounted on and/or inside the carrier may be devised to react with certain types of fluid (water, oil, gas, cement) present in the borehole fluid in order to grow in size and occupy gaps in the annular space.

In other embodiments, the carrier grooves may be inclined, diagonal or offset relative to the tubular axis. Where multiple grooves are present, these grooves may be angled or offset to one another.

The o-ring or o-rings may be similar to automotive shaft seal rings placed in a carrier, either in grooves or placed between two stop rings or between a stop ring and a centraliser. These o-rings may have an internal spring or some other method of internal support, reinforcement or increased elastic ‘memory’ property.

In one embodiment, the apparatus is placed in singular or multiple combinations and in any numbers in any casing or liner section across the well thereby adding a proportionate number of barriers to flow in the different annular spaces. In those areas where the product is used, there would be an alternation of cement, seal, cement, seal and so forth. Therefore the number of barriers to flow is increased thereby further hindering migration of gas or other fluids throughout the cement and towards surface.

In one embodiment, the apparatus is a host platform for a measuring or emitting device or means which provides information to the operator. Further, the turbulating element created by the profile of the apparatus may provide a protective cover, shield or interface layer for such a measuring or emitting device within the apparatus.

The apparatus may be created with a recess or receptacle for hosting third party objects or devices made from a variety or combination of second materials. For example, the object can be a pressure or temperature sensor and measurements are taken of it when in the cased hole by a suitable wire-line conveyed device.

In another method in accordance with an embodiment of the invention, either the turbulating element or the stop collar, or indeed any tubing mounted element, may include, for example have embedded therein, a pellet either containing or coated with a special dye (which could be chemical, nuclear, DNA imprinted or Nano based), a substance or any other tracer that is soluble in any solvent in any fluid phase present in the well. The purpose of this substance is to colour or ‘tag’ the fluids in contact with the stop collar such that if and when the fluids containing the tracer reach surface, they can be identified as coming from a particular location or area where the modified stop collar is positioned downhole, and thus the stop collar functions as a fail safe or beacon. The tracer material can be obtained from certified and qualified manufacturers.

A scheme of different colours or ‘tags’ may be used to differentiate tracers from different stop collars thereby allowing depths and individual tubulars to be identified allowing subsequent identification of problem intervals where the tagging product is used.

In another method according to an embodiment of the invention, either the turbulating element or the stop collar may include, for example have embedded therein, a pellet or other element either containing or coated with a special chemical compound, such as but not limited to solvents and water-wet surfactants, that could be soluble in any solvent in any fluid phase present in the well. The purpose of this substance is to, when in contact with exposed formation due to cementing problems, modify the formation wettability, generating a change in relative permeability that eventually affects well productivity.

In another embodiment of the present invention, the apparatus will have not only a turbulating element installed in its outer face to seal against the cement or formation (if cement is not present) but also a seal element installed in its inner face. Additionally, this element would grow in size to seal the space between the apparatus and the casing, liner or tubular. In this way, the occurrence of a continuous micro annulus between the inside circumference of the apparatus and the external surface of the tubular would be reduced.

Alternatively, a turbulating element, or swelling sealing material in another form, may be provided in or on an internal face of the apparatus. The material may be offset, either above or below, the turbulating element or other form of swelling sealing material provided on or in an external face of the apparatus.

Means may be provided for creating turbulence spaced from the swelling sealing material or attaching means.

The apparatus may comprise multiple turbulating elements (in one or both of its interior and exterior faces).

The apparatus may comprise a clutch or protuberance to engage other bodies installed in the tubular.

In another embodiment, the apparatus comprises two or more radially constrained swelling materials which upon interaction with the wellbore environment lead to a substantial longitudinal swelling (e.g. an extrusion event), followed by a radial swelling after the radial constraint has been destroyed or weakened by the wellbore fluids. The material, which may be in the form of a turbulating element, may be coated with a glue or other adhesive, or some other means for radially constraining the element, which is designed to degrade or embrittle over time and/or under certain conditions so as to act as a swelling restraint over a predetermined period of time and then, due to design, will age, thermally degrade or chemically react in the downhole environment to embrittle and crack or chemically dissolve and thereby stop constraining the material during the swelling process.

In another embodiment the turbulating element is placed on the rim (between the OD and ID) of the stop collar.

In another embodiment, an apparatus comprises a turbulating element, a measuring device as previously described, and a surface with dye. The apparatus is adapted to cooperate with a casing centraliser and a stop ring.

In another embodiment, an apparatus is comprised of a reinforced turbulating element with blades of steel or another material inserted on the element. The turbulating element may resemble an extended o-ring and it may not require a carrier or stop o-rings as the element may be slipped over the casing. This turbulating element would be of an internal diameter smaller than the OD of the casing so it would have to be stretched with a related device in order to be placed in the casing.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other aspects of the invention will now be described, by way of example, with reference to the accompanying drawing, in which:

FIGS. 1 a, 1 b, 1 c and 1 d illustrate cementing failure modes.

FIG. 2 a shows a stop collar according to the present invention and installed on a tubular.

FIG. 2 b shows a stop collar installed on a tubular which is positioned inside the borehole.

FIG. 2 c represents a top or bottom view of the stop collar of FIG. 2 b.

FIG. 3 a shows a stop collar installed in a tubular which is positioned inside the borehole, the secondary elements in the stop collar having reacted and interacted with the fluids in the borehole annulus.

FIG. 3 b represents a top or bottom view of FIG. 3 a.

FIG. 4 shows an embodiment in which a casing centraliser is coated by the turbulating element of an embodiment of the invention.

FIG. 5 shows a device that would rotate freely when fluid bypasses it.

FIG. 6 a shows a profiled or smooth turbulating material installed in a stop collar.

FIG. 6 b represents a top or bottom view of FIG. 6 a.

FIG. 6 c shows a stop collar with a profiled sealing material to induce turbulence.

FIG. 6 d represents a top or bottom view of FIG. 6 c.

FIG. 6 e represents a top or bottom view of a stop collar with a variable or changing surface finish in the turbulating element.

FIG. 7 a shows an apparatus with additional paths of turbulence through use of extended elastomeric elements.

FIG. 7 b shows a top or bottom view of FIG. 7 a.

FIG. 8 shows a stop collar being used to provide a secure datum point for a casing centraliser.

FIG. 9 shows a stop collar being used to provide a secure datum point for a casing centraliser and having a friction-reducing feature.

FIG. 10 a shows two stop rings retaining an o-ring.

FIG. 10 b shows two stop rings retaining three o-rings.

FIGS. 10 c and 10 d show a method in which an o-ring or multiple o-rings as turbulating elements are installed in a clustered fashion along a tubular.

FIG. 11 shows a stop ring and a centraliser retaining an o-ring.

FIG. 12 a shows a stop collar with a perpendicular groove (with respect to the collar) on it in which an o-ring is placed.

FIG. 12 b shows a stop collar with three perpendicular grooves (with respect to the collar) on it in which three o-rings are placed.

FIG. 13 a shows a stop collar with a diagonal groove (with respect to the collar) in which an o-ring is placed.

FIG. 13 b shows a stop collar with three diagonal grooves (with respect to the collar) in which three o-rings are placed.

FIG. 13 c shows a stop collar with two diagonal grooves and one perpendicular groove (with respect to the collar) in which three o-rings are placed.

FIG. 14 shows a method of augmenting the barriers to fluid flow in the different annular spaces of a well by means of installing multiple numbers of stop collars between the different casings.

FIG. 15 a, 15 b and 15 c show a method of hosting a measuring or emitting device in the stop collar, in FIG. 15 b, the device being installed between the stop and the pipe and in FIG. 15 c, the device being installed within the stop outer side and the turbulent path and a secondary material being used as a protection for the device.

FIG. 16 shows a stop collar with turbulating elements in internal and external faces.

FIG. 17 shows a stop collar with two receptacles to place turbulating elements in the interior and exterior of the casing.

FIG. 18 shows a stop collar similar to that in FIG. 17 but with turbulence blades in the sections of the stop collar when there is no turbulating element or attaching means to the tubular.

FIG. 19 shows a stop collar similar to that in FIG. 16 but with a clutch or protuberance in both extremes of the body of the stop collar.

FIGS. 20 a, 20 b, 20 c, 20 d and 20 e show the different stages in the swelling process of an apparatus comprised of two radially constrained swelling materials.

FIGS. 21 a and 21 b show an apparatus in which the turbulating element is placed on the rim (between the OD and ID) of the stop collar, in FIG. 21 a the turbulating element being in the top edge of the stop collar, and in FIG. 21 b the turbulating element being in the bottom edge of the stop collar.

FIG. 22 shows an apparatus comprised of a turbulating element, a measuring device, and a surface with dye, the apparatus cooperating with a casing centraliser and a stop ring.

FIG. 23 shows an apparatus comprised of a reinforced turbulating element with steel blades inserted on the element.

FIG. 24 shows an insert comprising a swelling elastomer layer in accordance with an embodiment of the present invention.

FIG. 25 shows seals (oil, water and gas) installed on a centraliser which will be positioned inside the borehole on the body of the tubular by two stop collars.

FIG. 26 shows seals (oil, water and gas) installed on a tubular which is positioned by two stop collars inside the borehole.

FIG. 27 shows seals (water, oil and gas) on the body of a centraliser positioned on a cemented tubular by stop collars.

FIG. 28 shows an embodiment of the device in which a length of casing is covered with a rubber like material with an OD equal to or less than the OD of the casing collars.

DETAILED DESCRIPTION

Referring now to FIGS. 2 a, 2 b and 2 c, there is provided a stop collar 10, composed of a carrier or body 11 and a turbulating element 15 installed in the carrier or body 11. The stop collar 10 is placed on the outer face of the casing 12 and has an outside diameter smaller than that of the collars used to connect the casing sections. The stop collar is secured to the tubular via set screws, grub screws, bolts, shear pins, adhesives or other suitable arrangement 13. The stop collar is designed to promote turbulence in bypassing fluid 16 during installation of the tubular 12 or during the cementing phase.

Turbulent paths 14 in the turbulating element 15 can be formed by a turbulating material, which includes but is not necessarily limited to rings, o-rings, foam, elastomers, thermoplastics, thermosets etc that, in contact with specific fluids 16, react and grow in size to ensure sealing against the cement 17 or the formation 18 (when cement 17 is not present due to cementing problems), to ensure the annular space 19 (as seen in FIGS. 3 a and 3 b) around the casing 12 is fully occupied and sealed.

Referring to the embodiment of FIG. 4, a turbulating element 15 a, comprising a cured elastomer, is bonded onto a centraliser 20 a shaped to induce flow turbulence, as described in U.S. Patent Application Publication No. 2003/0106719 A1 by Herrera. The centraliser is fixed in place by two stop rings 32 a.

Referring to the embodiment in FIG. 5, a tubular device 30 comprises a plurality of blades 33 on the outer face of the device, which blades 33 have a smaller outer diameter than of a centraliser 20. Thus, the action of the fluid being pumped past would cause the device 30 to rotate and thus enhance turbulence. The device 30 would not be fixed to the tubular 12. There would be a gap 31 between the device 30 and two simple stop rings 32.

In FIGS. 6 a and 6 b, the stop-collar 10 b uses a second material forming, an o-ring 40, to create a path 41 for turbulence. The stop is machined to provide step changes 42 in OD around the circumference of the o-ring.

In FIGS. 6 c and 6 d, the stop collar 10 c is made with a second coating or outer layer 43 which is applied to the stop so as to change the surface profile. This can promote turbulent flow. The stop collar 10 is held in place by two stop rings 32 c.

In FIG. 6 e, a stop collar 10 d is modified with a variable or changing surface finish 44 over the turbulent path 14 d and turbulating element 15 d, which affects the fluid flow of the cement. The surface finish will also improve the adherence of cement by the incorporation of enhanced surface roughness.

In FIGS. 7 a and 7 b, the apparatus is composed of two stop rings 32 e and a carrier or body lie in between. There is a gap 31 e between each stop ring 32 e and the carrier 11 e, so that the carrier 11 e is able to move up or down, limited by the stop rings 32 e. The carrier has a turbulating element 15 e with additional paths of turbulence through use of extended elastomeric elements 50 which, when rotated due to the passing of well fluid, cause additional turbulence through propeller type rotation.

In FIG. 8, a stop collar 10 f is used to provide a secure datum point for a casing centraliser 20 f. The stop collar 10 f has an inner diameter greater than the outside diameter of the tubular 12 f and an outer diameter which is less than that of the co-operating centraliser 20 f (as the purpose of the centraliser is to centralise the casing in a wellbore) such that the turbulating element 15 f of the stop collar 10 f would have minimum contact with the wellbore during installation of the casing.

In FIG. 9, the illustrated embodiment is similar to that of FIG. 8 with an exception that the stop collar comprises a tapered or bevelled edge region 60 to reduce the friction at the bearing surfaces between the centraliser 20 g and the stop 10 g.

In the embodiments shown in FIGS. 10 a and 10 b, one or more o-rings 70 are installed directly onto the body of the casing or liner tubular with the option of several combinations of triggering phase and are axially located between stop rings 32 h. Each o-ring 70 is designed to react and interact with a selected one or more fluid (e.g. water, oil, gas, cement) present in the borehole fluid in order to grow in size and occupy gaps in the annulus between the tubular and the bore wall.

In FIGS. 10 c and 10 d a method is diagrammatically represented in which apparatuses having an o-ring or multiple o-rings 70 a as turbulating elements are installed in a clustered fashion along a tubular 12 i. Further, any one cluster 75 of o-rings may be made up of a number of o-rings with different properties (i.e. will react with the wellbore environment and/or fluids in that environment) such that any particular cluster 75 will therefore react to a multitude of different wellbore conditions and/or fluids in that environment. Alternatively, the o-rings within a cluster may have the same properties. Further any individual tubular 12 may have a number of clusters 75 along its length.

In FIG. 11, an o-ring or multiple o-rings 70 j are trapped in place by a stop ring 32 j and a casing centraliser 20 j, such as the one described in U.S. Pat. No. 2003/0106719 A1 by Herrera.

In FIGS. 12 a and 12 b, an o-ring or o-rings 70 k, 70L are placed in grooves 80 k, 80L on a carrier sleeve 11 k, 11L that in turn is secured to the pipe 12 k, 12L via set screws, grub screws, bolts, shear pins, adhesives or other suitable arrangement 13 k, 13L. The grooves 80 k, 80L are perpendicular with respect to the tubular. Each o-ring is selected to react and interact with a selected fluid (e.g. water, oil, gas, cement) present in the borehole fluid in order to grow in size and occupy any gaps in the annulus.

In FIGS. 13 a, 13 b and 13 c the embodiment is similar to that of FIGS. 12 a and 12 b with the exception that the grooves 80 m,n,o are aligned in a diagonal manner, or any other offset, shape or pattern, relative to the pipe body axis. Each of the o-rings 70 m,n,o is placed in a groove 80 m,n,o and is adapted to react and interact with a selected fluid (water, oil, gas or cement).

In FIG. 14 an arrangement is illustrated in which stop collars 10 p are placed in multiple numbers per casing section 100, up to hundreds of collars per well. The collars thus provide a proportionate number of barriers to flow in the different annular spaces 19 p between the casing and the bore wall. In those areas where a stop collar 10 p is present there is an alternation of cement 18 p, sealing element 15 p, cement 18 p, turbulating element 15 p and so forth. This augments the number of barriers to flow and hence make it even more difficult for gas or other fluids to migrate in the annular spaces 19 p throughout the cement 18 p and towards surface 102.

FIGS. 15 a, 15 b and 15 c diagrammatically represent a method and embodiment by which a stop collar 10 q is adapted to act as a host platform for a measuring or emitting device 110 or other means by which information is provided to the user. An option can be to place an appropriate apparatus 110 in the gap 111 between the stop 10 q and the pipe 12 q (FIG. 15 b). The other option is to install the apparatus 100 within the stop outer side and the turbulent path 14 r and secondary material 15 r is used as a protective shield, cover or interface layer (FIG. 15 c).

In FIG. 16, in another embodiment of the present invention, the stop collar 10 s will have not only a turbulating element 15 s installed in its outer face to seal against the cement or formation (if cement is not present) but also a swelling seal element 115 installed in its inner face. This element 115 will grow in size to seal the space between the stop collar and the casing, liner or tubular.

In FIG. 17, the seal element 15 t installed in the internal face of the stop collar above or below where the turbulating element 15 t installed in the external face of the stop collar would be placed.

In FIG. 18, the stop collar is similar to that of FIG. 17 but the turbulence patterns 14 u would not be applied in the turbulating element 15 u but in the sections of the body 11 u when there is no turbulating element 15 u or attaching means to the tubular 12 u.

In FIG. 19, the stop collar 10 v is similar to that of FIG. 16 in that it has a sealing element 15 v installed in its inner and outer faces but it differs in that it has a clutch mechanism or protuberance 120 in both extremes of the body 11 v of the stop collar, which is attached by means 13 v to the pipe 12 v. The clutch mechanism 120 is adapted to engage other bodies installed in the tubular.

In FIGS. 20 a, 20 b, 20 c, 20 d and 20 e the different stages in the swelling process of a specially designed apparatus are shown. In FIG. 20 a, a stop collar 10 x has embedded, glued or installed two swelling materials 15 x which are radially constrained by a material 130. FIG. 20 b shows that after fluids come into contact with the swelling materials 15 x, there is swelling but this is longitudinal as the constraining material 130 restrains swelling in other directions. FIG. 20 c shows the result of a cementing operation in which cement 17 x surrounds the stop collar 10 x. FIG. 20 d shows a later stage in the life of the well in which cement 17 x surrounding the stop collar 10 x is cracked or damaged at 132. FIG. 20 e shows a how the constraining material 130, when weakened or embrittled, permits the swelling material 15 x to swell radially outwards and cover or fill the cracks or damage 132 in the cement 17 x surrounding the stop collar 10 x.

FIGS. 21 a and 21 b show an apparatus in which a turbulating element or swelling seal is placed on the rim or the edge (between the OD and ID) of a stop collar. In FIG. 21 a the turbulating element 15 y is in the top edge of a stop collar 10 y, in FIG. 21 b the turbulating element 15 z is in the bottom edge of the stop collar 10 z.

FIG. 22 shows a stop collar 10 aa comprising attaching means 13 aa, a turbulating element 15 aa, a measuring device 110, and a surface with dye 140. The stop collar 10 aa is cooperating with a casing centraliser 20 aa and a stop ring 32 aa.

On the dye 140 being exposed to a selected fluid, typically a hydrocarbon, indicative of a cement failure, the dye is released and may flow to surface. Analysis of the dye 140 identifies the stop collar 10 aa from which the dye has leached, and thus identifies the location in the well where the cement failure has occurred.

FIG. 23 shows an apparatus comprised of a reinforced turbulating element 15 ab with steel blades 150 inserted on the element.

In FIG. 24, an insert 90 in accordance with an embodiment of the present invention is shown. The insert 90 is provided with threads adapted to receive one or more grub screws 13 ac for securing the insert to a tubular (not shown). The insert 90 is formed by a casting process such as sand casting, die casting or by any other suitable process as would be recognised by someone skilled in the art. The insert 90 may be formed from steel or from any other suitable material such as aluminium, zinc, bronze or the like.

The insert 90 is coated in a layer of elastomer, preferably a swelling elastomer, the elastomer functioning as a protective layer for the insert 90. This protective layer advantageously reduces the possibility of corrosion of or on the insert 90 to increase the shelf life of the insert 90. Furthermore, the layer may prevent the formation of a galvanic cell resulting in corrosion of the insert 90. In operation, the layer resists abrasion of the insert by cement slurry or the like. The layer of swellable material applied around the insert 90 is preferably less than or equal to the cross sectional area of the insert 90.

The layer is moulded about the insert 90, preferably in an injection moulding process or the like. The insert 90 may be inserted into the injection mould with the grub screws (or the like) pre-inserted and secured within the mould, this being achieved by gripping means gripping a portion of the insert 90, attaching means securing the insert 90 through threaded holes within the insert 90, placing the insert 90 into a cavity substantially matching the ID and OD of the insert 90 or other suitable method. The insert 90 is secured within the mould cavity such that upon performing the moulding process, turbulating vanes, formed from the swellable material, are moulded onto the insert 90.

As described hereinabove, the swelling elastomer, on contacting a suitable trigger medium such as water, drilling fluid, oil or the like, will swell to fill a void between the tubular and the cement or the tubular and the bore as necessary.

The insert 90 may be is subjected to a further process in which a region of the elastomer layer covering the insert 90 is covered with a sheath or cover 92, the cover 92 permitting longitudinal expansion of the swellable material but which resists the radial expansion of the underlying swellable material.

The cover 92 may take the form of a coating, covering, treatment, mechanical barrier or any other suitable cover recognised by the person skilled in the art or may be formed as a secondary injection moulded process with a suitable material.

In one embodiment, the cover 92 is configured such that degradation of the adjacent bonded cement would lead to a corresponding degradation of the cover such that unswelled material would be free to expand radially should a void develop and where the swellable material encounters a triggering medium. The cover 92 is developed such that in the event of a parting of the cement, the outer layer will adhere to the cement.

The insert 90 comprises a lead edge 94 and a bearing edge 96. In use, the bearing edge 96 of the insert 90 is configured to provide a low friction bearing with an opposing centraliser (not shown). In one embodiment, the bearing edge 96 incorporates a lug for reaming centralisers and the opposing end incorporates a section of swellable material, this swellable material configured to resist radial expansion of the elastomer.

Reference is now made to FIG. 25 of the drawings, which illustrates a centraliser 200 comprising a central circumferential swelling elastomer seal 202. The seal 202 comprises three elements 202 a, 202 b, 203 c, each adapted to swell in response to exposure to a selected fluid, namely oil, gas and water. In use, the centraliser will typically be located on a tubular between two stop collars.

The seal 202 may be adapted to begin to swell immediately there is contact with an appropriate triggering or activating fluid, or the seal 202 may be provided with a protective coating which delays the onset of expansion.

FIG. 26 illustrates a seal arrangement 210 in which three bands of swelling elastomer 212 a, 212 b, 212 c are mounted directly to a casing 214 and are retained between stop collars 216. The elastomer may be adapted to provide only a small degree of swelling, sufficient to close any micro-annulus that might form between the seal arrangement 210 and surrounding set cement.

In other embodiments the elastomer may be mounted on a suitable carrier sleeve.

In certain embodiments of the invention a seal arrangement may host one or more devices or sensors for detecting or monitoring conditions or parameters in the bore including but not limited to pressure, temperature and stress. The measured conditions may provide an indication of formation condition or changes. In the arrangement 210 illustrated in FIG. 26, such a device 218 is provided in one or both of the stop collars 216.

The device 218 may operate continuously or intermittently, or may be selectively operator activated. Alternatively, a change in a selected condition may activate or awaken the device 218, for example an increase in applied stress due to a collapsing formation which may result in a partial pipe collapse. Of course changes in pressure and temperature will also change the stress experience by the pipe.

The sensed information is transmitted to surface by appropriate means, for example by wireless communication, via a signal carrier, such as a wire or optic fibre, or via the casing to an appropriate surface receiver. Alternatively, an operator may run logging or sensing tools through the tubing from time-to-time, to pick-up the sensor outputs.

At surface the sensed information may be processed and communicated to appropriate personnel to be analysed and, if necessary, appropriate remedial action may then be taken. The signal processor may be intelligent or otherwise configured such that selected events will be recognised, for example, a stress sensor output which is indicative of pipe collapse may general an alarm signal.

The device 218 may also operate to obtain information as the tubular is being run into a bore, or while other operations, such as a cementing operation, are taking place, which information may be useful to an operator.

FIG. 27 shows a bladed centraliser 220 mounted between two stops 222, 224 on a cemented casing. A swellable seal 226 comprising three o-rings, each responsive to a different fluid, is mounted centrally of the centraliser 220 OD.

The upper stop 222 and the opposing edge of the centraliser body feature a selectively engageable protrusion 228 and recess 230 such that while running in the centraliser 220 may be selectively rotated with the casing to remove tight spots.

FIG. 28 shows an alternative embodiment of the invention in which seal arrangements 240, in the form of sleeves of rubber-like swelling material, are provided on casing sections 242. The sleeves 240 have an OD less than the casing collars 244 and as such are protected against abrasion by the collars 244 while the tubular string is being run into the bore.

Swelling Material Triggering Fluid ethylene-propylene-copolymer rubber hydrocarbon oil ethylene-propylene-diene terpolymer rubber hydrocarbon oil butyl rubber hydrocarbon oil haloginated butyl rubber hydrocarbon oil brominated butyl rubber hydrocarbon oil chlorinated butyl rubber hydrocarbon oil chlorinated polyethylene hydrocarbon oil starch-polyacrylate acid graft copolymer Water polyvinyl alcohol cyclic acid anhydride Water graft copolymer isobutylene maleic anhydride Water acrylic acid type polymers Water vinylacetate-acrylate copolymer Water polyethylene oxide polymers Water carboxymethyl celluclose type polymers Water starch-polyacrylonitrile graft copolymers Water styrene butadiene Hydrocarbon ethylene propylene monomer rubber Hydrocarbon natural rubber Hydrocarbon ethylene propylene diene monomer rubber Hydrocarbon ethylene vinyl acetate rubber Hydrocarbon hydrogenised acrylonitrile-butadiene rubber Hydrocarbon acrylonitrile butadiene rubber Hydrocarbon isoprene rubber Hydrocarbon chloroprene rubber Hydrocarbon polynorbornene Hydrocarbon

Elastomer Name Chemical Name Triggering Fluid Type I Type II Type III NBR Butadiene- Hydrocarbon High Nitrile > 45% Medium Nitrile Low Nitrile < 30% Acrylonitrile Or CAN 30-45% ACN ACN Nitrile Content HNBR Hydrogenated Hydrocarbon — — — Nitrile EPDM Ethylene-Propylene- Water-Based — — — Diene Terpolymer Liquids FKM/FPM Fluorocarbon or Hydrocarbon Copolymer (A/E) Terpolymer (B or Tetrapolymer 67-69% (VITON, Flouroelastomer 65-65.5% F) 67% Fluorine Fluorine FLOUREL, Fluorine Content Content Content TECNOFLON) FFKM/FFPM Perfluoroelastomer Hydrocarbon — — — (CALREZ, CHEMRAZ) FEPM (TFE/P) Tetrafluoroethylene/ Hydrocarbon — — — (AFLAS, Propylene FLOURAZ) ECO Epichlorohydrin Hydrocarbon — — — copolymer and ethylene oxide homopolymer FVMQ Fluorosilicone Hydrocarbon — — — NR Natural Rubber Hydrocarbon — — — (cispolyisoprene) XNBR Carboxylated nitrile Hydrocarbon — — — 

1. An apparatus for mounting on a tubular for location in a wellbore, the apparatus comprising: a seal comprising a swelling sealing material configured to permit passage of fluid cement between the tubular and a surrounding wellbore wall, the sealing material configured for subsequent volumetric expansion into a space between the tubular and the surrounding wellbore wall which is void of set cement, the shape of the sealing material configured to increase turbulence in a fluid passing between the seal and the wellbore wall.
 2. The apparatus of claim 1, wherein the apparatus comprises a centraliser.
 3. The apparatus of claim 1 further comprising attaching means for securing the apparatus to the tubular.
 4. The apparatus of claim 1, wherein the attaching means includes at least one of set screws, grub screws, bolts, shear pins, adhesives, welding and threaded connections.
 5. The apparatus of claim 1 further comprising a turbulating element including swelling sealing material configured to interact with wellbore fluids and to swell in response thereto.
 6. The apparatus of claim 1 wherein the swelling sealing material is configured such that onset of swelling is delayed by a time selected to allow cement to be circulated and set between the tubular and the wellbore wall.
 7. The apparatus of claim 1, wherein the swelling sealing material is initiated by contact with a selected initiating material.
 8. The apparatus of claim 1, wherein the initiating material comprises a fluid.
 9. The apparatus of claim 8 wherein the fluid comprises at least one of liquid hydrocarbon, bitumen, gas, water, cement and a cement additive.
 10. The apparatus of claim 1, wherein the swelling sealing material is initiated by at least one of a selected triggering condition and triggering stimulus
 11. The apparatus of claim 10 wherein the triggering condition comprises one of applying an electric current, changing pressure, and changing temperature.
 12. An apparatus as claimed in claim 10, wherein the triggering condition comprises in-situ temperature increase caused by curing cement.
 13. The apparatus of claim 1, further comprising a carrier configured to provide a mounting for the swelling sealing material on the tubular.
 14. The apparatus of claim 13, wherein the carrier includes a turbulating element.
 15. The apparatus of claim 13, wherein the carrier is formed as a casting from at least one of card casting, die casting and wax casting.
 16. The apparatus of claim 1, further comprising at least one stop ring for mounting on the tubular.
 17. The apparatus of claim 16, wherein the stop rings are configured to secure a carrier and a turbulating element to the tubular.
 18. The apparatus of claim 1, further comprising an interacting device configured to at least one of determine, identify, record and measure at least one of pressure and temperature after cement is disposed in the space between the seal and the wellbore wall.
 19. The apparatus of claim 18, wherein the interaction device is configured to release at least one of a dye, paint and chemical in response to detecting of selected wellbore conditions.
 20. The apparatus of claim 1, wherein the apparatus is configured to create a predetermined pressure drop in fluid passing thereacross.
 21. An apparatus as claimed in claim 13, comprising turbulating elements adapted to form a corrugation along the carrier.
 22. The apparatus of claim 16, wherein the stop ring is adapted to act in co-operation with a casing centraliser.
 23. The apparatus of claim 1, further comprising a plurality of seals adapted to be provided along the length of at least one tubular in the wellbore.
 24. The apparatus of claim 24, wherein the seals are configured to be installed on an exterior of a plurality of different casing sizes in order to establish a plurality of barriers to fluid flow.
 25. The apparatus of claim 1, further comprising a sensor configured to at least one of determine, identify, register, measure and record at least one of pressure, temperature and fluid flow, and at least one parameter of the wellbore or a change of any of the foregoing.
 26. The apparatus of claim 25, wherein the device is configured to enable data access by at least one of a wireless, pipe-conveyed or wireline-conveyed tool.
 27. The apparatus of claim 25 wherein the sensor is coupled to a device is configured to release an identifying agent into the wellbore.
 28. The apparatus of claim 27, wherein the identifying agent is at least one of DNA and nucleonic or dye incorporated in the materials so as to identify fluids in contact with the device.
 29. The apparatus of claim 1 further comprising a galvanic protection element configured to protect to the tubular.
 30. The apparatus of claim 1, further comprising a stop collar having turbulating features to promote turbulence of bypassing fluid during installation of the tubular or during the cementing phase.
 31. The apparatus of claim 30, comprising a covering to isolate the turbulating features from fluid in the borehole.
 32. The apparatus claim 31, wherein the covering comprises a substantially impermeable membrane.
 33. The apparatus of claim 31, wherein the membrane is adapted to decompose with respect to at least one of time, pressure and temperature.
 34. The apparatus of claim 31, wherein the membrane is adapted to be breached after one of a selected time, a selected pressure application and a selected temperature application to enable a specific fluid to enter and to make contact with the turbulating element and initiate a swellable material therein. 